Anchor-based conveyance in a well

ABSTRACT

An anchor is placed in a wellbore to convey loads into a wellbore. The anchor is placed at some desired location in a wellbore and installed at that location using, for example, arms that penetrate into the formation surrounding the anchor. A line extends from the surface, wraps around a pulley in the anchor and attaches to the downhole end of the load. Tension is applied at the surface to the line to pull the load to a desired location in the wellbore. Optionally, the same or a second line can be attached to the uphole end of the load to reposition or retrieve the load. Alternatively, a powered anchor has a line drive device and a spool. A portion of a line extends from the anchor to the load. The line is spooled onto the spool by the line drive device, thereby pulling the load into the wellbore.

BACKGROUND

In the petroleum industry, before a downhole measurement or operationcan be performed in a well, a logging tool is deployed to a depth ofinterest. Current modes of deployment generally include wireline, drillstring, coil tubing (CT), slick line, and downhole tractors. Drillstring is generally considered the strongest mode and is capable ofexerting a force sufficient to deploy relatively large loads intovertical, horizontal, and deviated wells. It can be used to deploy alogging tool even into horizontal, vertical or deviated wells having doglegs. In contrast, a wireline deployment does not provide its own force,but instead relies on gravity to deploy. It therefore works well invertical wells and in deviated wells with small deviations fromvertical, but cannot deploy in horizontal wells or vertical wells withsevere dog legs. Traditionally, wireline conveyance has relied on havinga rig in place, though recently there is a trend to perform some of theoperations in a rig-less environment. Like wireline, a slick line is notdriven and as a result works reliably in vertical (or slightly deviated)wells.

Coil tubing is a driven deployment mode. It can work in horizontal,vertical, and deviated wells, but it is not as strong or rigid as drillstring, and therefore not as forceful. In a horizontal well, CT oftenworks for a few thousand feet, but, as it extends farther into thehorizontal well, its contact with the wellbore wall increases, and withit, friction. In long horizontal sections, the borehole wall frictionbecomes comparable to the applied force, causing the CT to buckle andbecome ineffective.

A downhole tractor is self-powered and provides its own conveyancemechanism. Tractors are typically used in cased wells and can carry aheavy load to a desired location. Tractors are designed to make shortstrides while pulling the load at the same time. This is not aparticularly efficient means of deployment.

There are many operations performed in or on a well after drilling andcompletion operations are finished and the rig is removed. Currentlymany of those operations are not closely monitored because it is notpractical to convey a logging tool into the well while performing theparticular operation. This is especially true in highly deviated andhorizontal wells.

SUMMARY

An anchor is placed in a wellbore to convey loads into a wellbore. Theanchor is placed at some desired location in a wellbore and installed atthat location using, for example, arms that penetrate into the formationsurrounding the anchor. A line extends from the surface, wraps around apulley in the anchor and attaches to the downhole end of the load.Tension is applied at the surface to the line to pull the load to adesired location in the wellbore. Optionally, the same or a second linecan be attached to the uphole end of the load to reposition or retrievethe load. Alternatively, a powered anchor has a line drive device and aspool. A portion of a line extends from the anchor to the load. The lineis spooled onto the spool by the line drive device, thereby pulling theload into the wellbore.

This summary is provided to introduce a selection of concepts that arefurther described below in the detailed description. This summary is notintended to identify key or essential features of the claimed subjectmatter, nor is it intended to be used as an aid in limiting the scope ofthe claimed subject matter.

BRIEF DESCRIPTION OF THE DRAWINGS

The present disclosure is best understood from the following detaileddescription when read with the accompanying figures. It is emphasizedthat, in accordance with the standard practice in the industry, variousfeatures are not drawn to scale. In fact, the dimensions of the variousfeatures may be arbitrarily increased or reduced for clarity ofdiscussion. Embodiments are described with reference to the followingfigures. The same numbers are generally used throughout the figures toreference like features and components.

FIG. 1 is a schematic drawing showing an embodiment of an anchor in awellbore, in accordance with the present disclosure.

FIG. 2 is a schematic drawing showing the anchor of FIG. 1 in aretracted configuration, in accordance with the present disclosure.

FIG. 3 is a schematic drawing showing the anchor of FIG. 1 in anextended configuration, in accordance with the present disclosure.

FIG. 4 is a schematic drawing showing an embodiment of an anchor with alocomotion mechanism, in accordance with the present disclosure.

FIG. 5 is a schematic drawing showing an embodiment of an anchor on aloading dock and with a locomotion mechanism, in accordance with thepresent disclosure.

FIG. 6 is a schematic drawing showing wellbore pulleys used inconjunction with two lines and surface tensioning devices, in accordancewith the present disclosure.

FIG. 7 is a flowchart for at least one workflow embodiment, inaccordance with the present disclosure.

FIG. 8 is a schematic drawing showing a powered anchor in a wellbore, inaccordance with the present disclosure.

FIG. 9 is a schematic drawing showing a powered anchor in a wellboreused in conjunction with a power and data cable, in accordance with thepresent disclosure.

FIG. 10A is a schematic drawing showing, in cross-sectional view, aninsert having wellbore pulleys used in conjunction with two lines andsurface tensioning devices, in accordance with the present disclosure.

FIG. 10B is a schematic drawing showing, in end view, the insert of FIG.10A, in accordance with the present disclosure.

DETAILED DESCRIPTION

It is to be understood that the following disclosure provides manydifferent embodiments, or examples, for implementing different featuresof various embodiments. Specific examples of components and arrangementsare described below to simplify the present disclosure. These are, ofcourse, merely examples and are not intended to be limiting. Inaddition, the present disclosure may repeat reference numerals and/orletters in the various examples. This repetition is for the purpose ofsimplicity and clarity and does not in itself dictate a relationshipbetween the various embodiments and/or configurations discussed.Moreover, the formation of a first feature over or on a second featurein the description that follows may include embodiments in which thefirst and second features are formed in direct contact, and may alsoinclude embodiments in which additional features may be formedinterposing the first and second features, such that the first andsecond features may not be in direct contact.

Some embodiments will now be described with reference to the figures.Like elements in the various figures may be referenced with like numbersfor consistency. In the following description, numerous details are setforth to provide an understanding of various embodiments and/orfeatures. However, it will be understood by those skilled in the artthat some embodiments may be practiced without many of these details andthat numerous variations or modifications from the described embodimentsare possible. As used here, the terms “above” and “below,” “up” and“down,” “upper” and “lower,” “upwardly” and “downwardly,” and other liketerms indicating relative positions above or below a given point orelement are used in this description to more clearly describe certainembodiments. However, when applied to equipment and methods for use inwells that are deviated or horizontal, such terms may refer to a left toright, right to left or diagonal relationship, as appropriate. It willalso be understood that, although the terms first, second, etc. may beused herein to describe various elements, these elements should not belimited by these terms. These terms are used to distinguish one elementfrom another.

The terminology used in the description herein is for the purpose ofdescribing particular embodiments only and is not intended to belimiting. As used in the description and the appended claims, thesingular forms “a,” “an” and “the” are intended to include the pluralforms as well, unless the context clearly indicates otherwise. It willalso be understood that the term “and/or” as used herein refers to andencompasses any and all possible combinations of one or more of theassociated listed items. It will be further understood that the terms“includes,” “including,” “comprises,” and/or “comprising,” when used inthis specification, specify the presence of stated features, integers,steps, operations, elements, and/or components, but do not preclude thepresence or addition of one or more other features, integers, steps,operations, elements, components, and/or groups thereof.

As used herein, the term “if” may be construed to mean “when” or “upon”or “in response to determining” or “in response to detecting,” dependingon the context. Similarly, the phrase “if it is determined” or “if [astated condition or event] is detected” may be construed to mean “upondetermining” or “in response to determining” or “upon detecting [thestated condition or event]” or “in response to detecting [the statedcondition or event],” depending on the context.

A system and method to provide an anchor that, once deployed andinstalled in a wellbore, is capable of deploying loads into and out ofthe well is disclosed. The conveyance of the anchor and the pulling ofthe load are decoupled into separate steps. The anchor may be positionedand installed, for example, at the far end of the well (toe) and used topull a load (e.g., a logging tool) into some desired location in thewell. The anchor may use a line connected to the load to exert a pullingforce on the load. This is in contrast with wireline and slick linedeployments which do not provide any driving force and rely solely onthe force of earth's gravity to deploy the load into the well. Thepulling force of the anchor is also different from the forces applied bydrill string or coil tubing since their forces are pushing (compressive)rather than pulling (tensile). The anchor may be deployed and installedusing an independent conveyance mechanism or it may be self-propelled.

As alluded to above, an anchor is a mechanical unit that goes to or isplaced at a desired location in a generally non-vertical section of awellbore and attaches itself to the borehole wall. The attachment to thewall is sufficiently strong so that when pulling forces are applied tothe anchor during operations, the anchor itself does not move. In oneembodiment, the anchor has a pulley and line that can be used to drag atool, for example, along the length of the wellbore to a desiredposition, including up to the anchor. For example, the anchor may have apassive pulley that a line (e.g., slickline or wireline) can wrap aroundand return to the upper end of the well. At the upper end, in operation,a pulling force is applied to the returning or incoming portion of theline. The line passing over the pulley has its other (outgoing) endattached to a load (e.g., a logging tool or any other unit to beconveyed into the borehole). The force exerted by the incoming orreturning line to the load is a pulling force since the pulley changesthe direction of the force being applied to the incoming end.

FIG. 1 schematically shows a section of a horizontal well 12 with ananchor 14 positioned at the end (toe) of the wellbore. Anchor 14 doesnot have to be installed at the end of the wellbore. It may be deployedto any desired location in the wellbore so long as the surroundingwellbore wall permits the anchor 14 to securely attach at that location.The anchor 14 has a pulley 16, around which a line 18 wraps. One end ofthe line, the incoming end, extends to the upper end of well 12 andengages a drive mechanism 17, such as a motor, capable of exerting atensile force on line 18. The other (outgoing) end of line 18 isattached to a load 19. The arrow shown in FIG. 1 on the inbound end ofline 18 (i.e., towards motor 17) indicates a pulling action to the left.This force is re-directed to become a pulling force on the load 19 (tothe right), as shown by the oppositely directed arrow on line 18. Noteline 18 can form a closed loop, around or through drive mechanism 17 andattaching to the opposite (upward) end of load 19. Mechanism 17 canapply a tensile force to line 18 in either direction, thereby allowingload 19 to be pulled into the wellbore or out of the wellbore.

The embodiment of anchor 14 shown in FIG. 1 is shown in more detail inFIG. 2. Anchor 14 comprises a support member 21. Arms 22 are rotatablyattached to support member 21 and can pivot around pivot points 23.Pivot points 23 allow the free ends of arms 22 to extend toward or awayfrom the wellbore wall. In this embodiment, two arm sections 25 areshown, but the number of arm sections 25 can be one or more, dependingon the maximum pulling force anchor 14 is expected to handle. Also, eacharm section 25 shows two arms 22, but the number of arms 22 can be moreor fewer. Pulley 24 is attached to support member 21 and can rotatearound axle 26. In the drawing of FIG. 2, the arms 22 are shown in aclosed or retracted position which is their normal configuration duringthe deployment phase (i.e., when anchor 14 is being delivered to adesired location).

Upon reaching the desired location, arms 22 are allowed to extend andengage the borehole wall. The extension can be effected, for example, bya spring force on arms 22, as shown in FIG. 3. The spring force may betriggered to apply once anchor 14 is in place, or arms 22 may becontinuously pushed radially outward by springs 32, causing the freeends or tips of arms 22 to brush against the borehole wall while theanchor is moved towards the installation location in the directionindicated by arrow 27. Arms 22 will consequently rub against theborehole wall but will not attachingly engage with the wall while theforce is in the direction of arrow 27. That is, arms 22 will notattachingly engage with the wall unless there is a force on anchor 14 inthe direction indicated by arrow 28. The length of arms 22 is chosen tobe longer than the radius of the borehole. That ensures that anyparticular arm 22, when engaged with the borehole wall, will make anangle 34 with support 21 that is less than 90 degrees. The springs 32shown can be of many different designs and strengths (i.e., springconstants). Note that once a force in the direction 28 is applied toanchor 14, the tips of arms 22 will penetrate into the formation aroundthe borehole wall and prevent anchor 14 from moving in the direction 28.As larger forces are applied to anchor 14, the arms 22 will furtheroutwardly extend and penetrate even deeper into the formation, ensuringthat anchor 14 does not move. The arm tips may be sharpened to enhancetheir ability to penetrate the formation. Other tip or arm designs maybe used.

The embodiment of anchor 14 shown in FIGS. 2 and 3 is passive in that itis delivered to the desired location by a force acting in direction 27.Once the direction of force is switched to direction 28, arms 22penetratingly engage the formation to fix anchor 14 in the wellbore.Such an anchor 14 does not need its own source of power for itsinstallation or operation. However, it requires a deploying orconveyance mechanism to deploy and install it. The deploying mechanismmay be, for example, a drill string, a tractor or CT. While thoseconveyance mechanisms are needed to deploy anchor 14, they are used inthe deployment/installation phase. After that, anchor 14 can assistfuture deployments.

In an alternate embodiment, anchor 14 can be made more self-contained.This may entail many different levels of sophistication. For example, asalluded to above, in the installation phase, the arm extension mechanismcan be made to be activated on command rather than having an activespring 32. In this case, the arm tips are not rubbing against theformation wall while anchor 14 is moved to the desired location. As aresult, there is less friction between anchor 14 and the borehole wall,which makes it easier to deploy anchor 14 to the desired location. Thearm extension mechanism may be powered by a battery, for example, oranchor 14 may be attached to a power cable at the time of installationand extension. Unless it is desired to have power available on anchor 14for other purposes, once anchor 14 is in place and operational, thepower cable can be disconnected and removed (i.e., pulled back to thesurface).

Unlike tractors that carry a load with them while they move in theborehole, anchor 14 carries a minimum load while being deployed. Duringdeployment, the forces involved include the weight of anchor 14 and theweight of line 18 (and their corresponding frictional forces). To easethe deployment further, a lightweight temporary line or leader 45 can beused in the deployment phase (see FIG. 4). Once installation iscomplete, the temporary line or leader 45 can be used to convey theoperational line 18 in place.

Anchor 14 may additionally be equipped with a locomotion mechanism. Anexample is shown in FIG. 4, wherein an electric motor (not shown) isused to drive a belt 43 (via wheels 42), enabling anchor 14 to traversewell 12. More specifically, in the embodiment of FIG. 4, a carrier 41 isused to carry anchor 14 to some desired location in the wellbore.Carrier 41 is equipped with wheels 42 which are rotated by a motor (notshown) which in turn is powered by an electrical line (not shown) orbattery. The rotation of wheels 42 causes rotation of a belt 43 (similarto what is used in a bulldozer or snow mobile, for example), which thencauses the carrier to move along the length of the borehole. Thus,anchor 14 may be self-propelled. As stated above, leader 45 represents atemporary line in this particular embodiment, but may also representoperational line 18 in an alternate embodiment that does not use aleader 45.

In an alternate embodiment, leader 45 is not attached to anchor 14 whileanchor 14 is carried to its desired location. Rather, temporary line 45(or line 18) is conveyed to anchor 14 by a second trip of carrier 41 andinstalled. Carrier 41 may be an integral part of anchor 14. In thisunitary embodiment, anchor 14 can be retrieved, if desired, by drivingcarrier 41 in the reverse direction.

In yet another alternate embodiment, carrier 41 is independent fromanchor 14 and may be pulled out of the well once anchor 14 is installedin the desired location. That is, in the embodiment shown in FIG. 5,carrier 41 has a loading dock 46 on which to place anchor 14 whiledeploying anchor 14 to its desired location. Once at that location,anchor 14 is released and carrier 41 is pulled back. In the embodimentsof FIGS. 4 and 5, arms 22 remain in the closed position while anchor 14is delivered to the desired location. Also, loading dock 46 has, in theembodiment shown, non-driven wheels 47 on which it rolls.

In addition to pulley 16 (or 24), which is joined to support member 21of anchor 14, there may optionally be other, additional pulleys tofacilitate the movement of line 18 along the length of the well 12. FIG.6 shows an example wherein multiple additional pulleys (e.g., 61, 62)are placed in the well. Since horizontal wells generally are drilled bystarting with a vertical section of the well before sidetracking into adeviated section of the well and eventually transitioning to ahorizontal section, additional pulleys 61, 62 may be placed at thetransition zones, such as the end of vertical section or the beginningof the horizontal section.

In one implementation of this embodiment, a first line 74 is wrappedaround a first winch 65 at an uphole location. First line 74 is passedover a surface pulley 63 which is located over the borehole opening.First line 74 passes through vertical section 66 of the well beforereaching additional pulley 62, which is located (in this embodiment) atthe transition between the vertical section 66 and the deviated section67 of the well. First line 74 is placed over additional pulley 62.Having first line 74 ride on additional pulley 62 helps reduce thecontact between first line 74 and the borehole wall. Such contact isavoided since it may lead to erosion of the borehole wall and first line74, in addition to producing undesirable frictional drag. First line 74extends through the deviated section 67 of the well until it reaches thetransition between the deviated section 67 and the horizontal section 68of the well. Here additional pulley 61 is installed to guide first line74. The additional pulleys 61, 62 are small enough so as not to restrictthe movement of a load 69 through the well.

First line 74 extends to and wraps around pulley 16 of anchor 14, beforeextending back uphole and reaching the downhole end 72 of load 69. Firstline 74 may be used to pull load 69 toward or to the end of the well.There may also be a second line 76 that may be used to pull load 69 outof the well. Second line 76 is attached to the uphole end 71 of load 69and extends to an uphole location. Similar to that described above,further additional pulleys 78, 79 may be positioned more or lessdiametrically opposite additional pulleys 61, 62, respectively, to guidesecond line 76. Second line 76 engages and travels on additional pulleys78, 79 and ultimately passes over another surface pulley 63 and wrapsaround a second winch 64. Additional pulleys 78, 79 serve in a capacitysimilar to additional pulleys 61, 62 (i.e., reduce friction anderosion). While in the embodiment shown additional pulleys 61, 62, 78,79 are installed more or less pairwise (i.e., 61/78, 62/79)diametrically across the wellbore, other configurations are possible.

FIGS. 10A and 10B show, in cross-section and end view, respectively, anembodiment in which an insert 1010 may be delivered to and disposed in aspecific location in the well, such as where pulley 61 of FIG. 6 islocated. In the embodiment shown in FIGS. 10A and 10B, insert 1010 has acylindrical shell frame 1020 that has substantially the same outerdiameter as the diameter of the well and can be anchored to the boreholewall (not shown). Insert 1010 comprises at least one pulley (e.g., theone labeled 61 since it serves the equivalent role in this embodiment aspulley 61 of FIG. 6) that can be used to guide and support line 74,which is located at or near the ceiling of the well. Line 74 may becaged and supported by a cover 1030 to prevent line 74 from becomingmisaligned with pulley 61 when line 74 is not in tension. When line 74is pulled, tension in the line causes it to engage the groove of pulley61. Insert 1010 may contain an additional pulley 78 on or near the floorof the well that guides and supports line 76. In this case, line 76 runsbetween pulley 78 and cylindrical frame 1020. A cover 1030 may be usedwith pulley 78, but the pulley structure tends to keep line 76reasonably aligned with pulley 78 and a tensile load in line 76 tends topull it into engagement with pulley 78. Multiple inserts 1010 may bedisposed in the well.

Operationally, for the embodiment of FIG. 6, before load 69 isintroduced into the well, first line 74 is run from the winch 65,through the pulleys (e.g., 63, 62, 61), and back to the uphole location.Note, at this point, all of second line 76 is wrapped around secondwinch 64. The free end of first line 74 is attached to what will be thedownhole end 72 of load 69 and the free end of second line 76 isattached to what will be the uphole end 71 of load 69. Load 69 isintroduced into the well while it is being supported (via tension) bysecond line 76. The earth's gravity helps load 69 slide to, or at leastclose to, the lower end of deviated section 67. While that is happening,first line 74 is not providing any pulling force unless there is arestraining force (such as that arising from traversing a dogleg, forexample) that necessitates more force than that already provided bygravity. Once load 69 gets to a position where it cannot go any fartherwithout assistance, second line 76 is made loose (slack) so that it doesnot impede any further downward motion of load 69. At the same time,first line 74 is tightened, causing a pulling force on load 69. This iscontinued until load 69 reaches its desired location in the well. Theprocess of removing load 69 out of the well is the reverse. First line74 is made loose while second line 76 is tightened and pulled. Thismoves load 69 in the uphole direction. This is continued until load 69reaches the uphole location.

In another embodiment, the drive mechanism 17 located uphole in theabove-described embodiment may be moved downhole. For example, drivemechanism 17 may be lowered into the well and allowed to descend untilit reaches a certain depth (e.g., the bottom of the verticalsection—this may be at or near the same location as additional pulley62). With this arrangement, the number of additional pulleys may bereduced and the rubbing contact of the line (18 or 76) against theborehole wall further minimized. This would reduce the friction betweenthe line and the wall and also minimize any erosion or sticking of theline to the borehole wall.

Lines 74 and 76 (both or only one) may be purely mechanical and used topull load 69 in or out of the well. In this case, the line (74 and/or76) is generally lighter and easier to move through the well compared toheavier electro-mechanical cables. If solely mechanical lines are used,the tools or instruments that are part of load 69 that requireelectrical power may be operable using batteries. Further, the datameasured by those devices is not available in real-time. The data can bedownloaded after the operation is complete and the load 69 is brought tothe surface.

In an alternate embodiment, at least one of the lines (74, 76) is awireline that can be used to provide power and telemeter (i.e.,electronically transfer) data. A wireline is generally heavy andsomewhat inflexible and is therefore generally more appropriate to bethe second line 76.

Anchor 14 may have centralizers to center itself within the wellborewhile or before the arms are released. That helps ensure that thepulling load is evenly distributed over the different arms 22 for bestpulling resistance.

In yet another embodiment, shown in FIG. 8, a powered anchor 80comprises a mechanism to generate a pulling force. In this embodiment,powered anchor 80 contains a line drive device 82 having, for example,an electric motor and gear system. Line drive device 82 can be used topull a load (downhole) and store a line 86 within powered anchor 80.Powered anchor 80 does not require a separate driving mechanism locateduphole, such as a surface winch, and as a result there is no need for apulley or a dedicated line going from powered anchor 80 directly to thesurface location. That is, powered anchored 80, shown at the end of ahorizontal well in FIG. 8, is self-contained. The electric motor in linedrive device 82 may be powered from uphole. Power may be delivered topowered anchor 80 through line 86, for example. Line 86 is used to pullthe load in the downhole direction and, as such, is strong enough tohandle the corresponding forces. A power line (not shown) may be placedin a space in the interior region of line 86 for power transfer topowered anchor 80. The technique of making line 86 with electrical wireand logic wires is well known in the wireline art. A first end of line86 attaches to powered anchor 80. Electrical power and/or commands canbe extracted and used to operate powered anchor 80. A second part ofline 86 is attached to (or near) the downhole end of a load. Line 86 mayextend through or around the load, be secured to (or near) the upholeend of the load, and continue uphole to the surface. Line 86 may bejoined to an uphole drive mechanism such that line 86 may be used towithdraw the load (with line drive device 82 in neutral or reverse).

As stated above, the electric motor and other mechanical and electricalcomponents needed to operate powered anchor 80 are housed in line drivedevice 82 of powered anchor 80. While a load is pulled toward poweredanchor 80, line 86 wraps around a spool 84 for storage. The wrapping canbe done in multiple layers to save space. The maximum length of lineavailable depends on the storage capacity of powered anchor 80. Storagecapacity factors include, but are not limited to, the length of spool84, the diameter of spool 84, and the number of layers of line 86wrapped around spool 84. The last factor depends on, among other things,the diameter of line 86 and the space between spool 84 and the boreholewall. These parameters may be adjusted to produce a desired line length.

Like the passive embodiments described above, powered anchor 80 may havemultiple arms 81 that are longer than the radius of the well and serveto secure powered anchor 80 in the well.

FIG. 9 shows an alternate embodiment in which powered anchor 80 may beconnected both mechanically to a load 69 and electrically to an upholedevice (not shown). Load 69 may be pulled in two directions using twolines (86, 88). Line 86 may be used by powered anchor 80 to pull load 69deeper into the well. Line 88 may be used to pull load 69 in the upholedirection. In the embodiment shown, both lines are equipped to provideelectrical power and command lines. Provisions may be made in thestructure of load 69 to connect the power and command lines of lines 88and 86. When the load 69 is a logging tool, for example, theconnectivity is generally already built into the tool since those toolsare commonly designed to accept and transfer electrical power and datafrom and to other apparatuses above and below the tool. For other loads,such as a container of acid for matrix acidization, for example, wiring89 from one side of load 69 to the other, along with connectors on eachside of load 69, can provide the desired connectivity.

In a typical deployment scenario, line 86 is connected to the downholeside of load 69. The upper portion of line 88 is spooled on a surfacewinch 64, and the free (downhole) end is connected to the uphole end ofload 69. Load 69 is allowed to enter the well and make a controlled fallunder earth's gravity, during which time line 88 is extended and line 86is spooled. When load 69 reaches a dogleg or the end of its controlledfall, line drive device 82 in powered anchor 80 provides the force topull load 69 towards powered anchor 80 via line 86. Pulling load 69 outof the well is performed by reversing the forces on lines 88 and 86.Here line 86 is made slack while line 88 is pulled with sufficient forceto move load 69 in the uphole direction.

Attention is now directed to processing procedures, methods, techniques,and workflows that are in accordance with some embodiments. Someoperations in the processing procedures, methods, techniques, andworkflows disclosed herein may be combined and/or the order of someoperations may be changed. It is important to recognize that geologicinterpretations, sets of assumptions, and/or domain models may berefined in an iterative fashion. This concept is applicable to theprocessing procedures, methods, techniques, and workflows discussedherein. This iterative refinement can include use of feedback loopsexecuted on an algorithmic basis, such as at a computing device and/orthrough manual control by a user who may make determinations regardingwhether a given step, action, template, or model has become sufficientlyaccurate.

FIG. 7 shows a flowchart illustrating an embodiment in accordance withthis disclosure. In this embodiment, the workflow comprises disposing ananchor in a first desired location in a wellbore (702); installing theanchor into a formation surrounding the anchor (704); using a linemoveably constrained by the anchor to pull a load to a second desiredlocation in the wellbore (706); and optionally, using the line toreposition or retrieve the load (708).

The foregoing outlines features of several embodiments so that thoseskilled in the art may better understand the aspects of the presentdisclosure. Those skilled in the art should appreciate that they mayreadily use the present disclosure as a basis for designing or modifyingother processes and structures for carrying out the same purposes and/orachieving the same advantages of the embodiments introduced herein.Those skilled in the art should also realize that such equivalentconstructions do not depart from the scope of the present disclosure,and that they may make various changes, substitutions, and alterationsherein without departing from the scope of the present disclosure.

The Abstract at the end of this disclosure is provided to comply with 37C.F.R. §1.72(b) to allow the reader to quickly ascertain the nature ofthe technical disclosure. It is submitted with the understanding that itwill not be used to interpret or limit the scope or meaning of theclaims.

While only certain embodiments have been set forth, alternatives andmodifications will be apparent from the above description to thoseskilled in the art. These and other alternatives are consideredequivalents and within the scope of this disclosure and the appendedclaims. Although only a few example embodiments have been described indetail above, those skilled in the art will readily appreciate that manymodifications are possible in the example embodiments without materiallydeparting from this invention. Accordingly, all such modifications areintended to be included within the scope of this disclosure as definedin the following claims. In the claims, means-plus-function clauses areintended to cover the structures described herein as performing therecited function and not only structural equivalents, but alsoequivalent structures. Thus, although a nail and a screw may not bestructural equivalents in that a nail employs a cylindrical surface tosecure wooden parts together, whereas a screw employs a helical surface,in the environment of fastening wooden parts, a nail and a screw may beequivalent structures. It is the express intention of the applicant notto invoke 35 U.S.C. §112, paragraph 6 for any limitations of any of theclaims herein, except for those in which the claim expressly uses thewords ‘means for’ together with an associated function.

What is claimed is:
 1. A method, comprising: disposing an anchor in afirst desired location in a wellbore; installing the anchor into aformation surrounding the anchor; and using a line moveably constrainedby the anchor to pull a load to a second desired location in thewellbore.
 2. The method of claim 1, further comprising using the line toreposition or retrieve the load.
 3. The method of claim 1, wherein thedisposing an anchor comprises using a self-propelled anchor.
 4. Themethod of claim 1, wherein the installing the anchor comprises causinganchor arms to penetratingly engage the formation.
 5. The method ofclaim 1, wherein the installing the anchor comprises releasing anchorarms from a retracted position and causing the anchor arms topenetratingly engage the formation.
 6. The method of claim 1, whereinthe using a line moveably constrained by the anchor to pull a loadcomprises using a drive mechanism to produce a tensile force in theline.
 7. The method of claim 1, wherein the line and the load form aclosed loop.
 8. The method of claim 1, further comprising using a leaderin conjunction with the line.
 9. An apparatus, comprising: an anchorhaving one or more anchor arms, wherein the anchor is disposed andinstalled in a wellbore; a first line moveably constrained by theanchor; and a drive mechanism capable of producing a tensile force inthe first line.
 10. The apparatus of claim 9, further comprising alocomotion device.
 11. The apparatus of claim 9, wherein the first lineis moveably constrained by an anchor pulley.
 12. The apparatus of claim9, wherein the first line is further moveably constrained by one or morewellbore pulleys disposed in various locations in the wellbore.
 13. Theapparatus of claim 9, further comprising a biasing force mechanismcapable of applying a bias force to the one or more anchor arms.
 14. Theapparatus of claim 13, wherein the one or more anchor arms have aretracted configuration and an extended configuration, and the biasingforce mechanism can release the one or more anchor arms from theretracted configuration and drive them to the extended configurationand/or release the one or more anchor arms from the extendedconfiguration and drive them to the retracted configuration.
 15. Theapparatus of claim 9, further comprising a leader in lieu of the firstline.
 16. The apparatus of claim 9, wherein the first line compriseselectrical and/or logic wires.
 17. The apparatus of claim 9, furthercomprising a second line attached to a load disposed in the wellbore.18. The apparatus of claim 9, wherein the drive mechanism is disposed onthe anchor, elsewhere in the wellbore, or at the earth surface.
 19. Anapparatus, comprising: an anchor comprising one or more anchor arms, aline drive device, and a spool, wherein the anchor is disposed andinstalled in a wellbore; and a line that extends from the anchor intothe wellbore and is capable of being spooled onto the spool by the linedrive device; wherein the line drive device is capable of producing atensile force in at least the portion of the line that extends into thewellbore.
 20. The apparatus of claim 19, wherein the portion of the linethat extends into the wellbore is attached to or near a downhole end ofa load.
 21. The apparatus of claim 20, wherein the line extends throughor around the load, is attached to or near an uphole end of the load,and further extends to a drive mechanism capable of producing a tensileforce in the line.
 22. The apparatus of claim 19, wherein the linecomprises electrical and/or logic wires.